Energy coordination system

ABSTRACT

A system for scheduling the generation of energy in an energy distribution network having a plurality of customers and a plurality of energy sources, wherein the customer chooses an energy provider from which to receive its energy. The system comprises memory in communication with the input. The memory is configured to store a schedule for each customer, the schedule setting forth the predicted energy consumption for that customer over a predetermined period of time. A processor is in communication with the memory. The processor is configured to sum the schedules for each energy provider thereby creating a load schedule for each energy provider. An output interface is in communication with the processor. The output interface is configured to output each of the load schedules.

TECHNICAL FIELD

[0001] The present invention is related to an energy coordinationsystem, and more particularly, to an energy coordination system thatfacilitates a customer's ability to choose its energy provider.

BACKGROUND

[0002] The traditional model for electric utilities is shown in FIG. 1.In this model, an electric utility serves energy users or customers 108(i.e., load) with its own facilities 100, which includes a generator102, a transmission network 104, and a distribution network 106. Atransformer station 105 is connected between the transmission network104 and the distribution network 106. A customer 108 cannot choosebetween alternative sources of energy. The customer 108 must buy energyfrom the utility that operates in its geographic region.

[0003] Referring to FIG. 2, power grids 110 and 112 are organized intoControl Areas 114 and 116, respectively, which are electrical systemsbounded by interconnection (i.e., tie-line) metering 118 and telemetry.The load between adjacent Control Areas 114 and 116 is balancedaccording to a predetermined schedule. If excess demand for electricityis generated in one Control Area 114, it will receive electricity fromadjacent Control Areas 116, which disrupts the balance. Generators 120and 122 in the Control Areas 114 and 116 must then adjust theirgeneration to return the balance to zero. The Control Area 116 that isproviding the excess electricity then bills the other Control Area 114for expenses caused by the deviation.

[0004] A problem with this current model of electric utilities is thatthere is not currently any way to allocate the billings for thedeviation in an amount proportional to the individual customer'sdeviation. Rather, the cost of the deviation is divided among all of thecustomers regardless of whether their usage exceeded a predictableamount. Another problem is that customers who do exceed their predictedload cannot freely choose the generator, or the Control Area, from whichthey receive electricity to meet their excess demand.

[0005] In an effort to stimulate competition and lower energy prices,the electric utility industry is being deregulated. In theory,deregulation will allow energy users to freely choose the provider fromwhich they purchase energy. However, most models for the deregulatedutility industry only permit limited customer choice. One reason is thatfull customer choice is not possible without a system and method ofuniversally scheduling load and generation, controlling the distributionof energy, and accurately allocating deviations to the customers andgenerators that created them.

[0006] Accordingly, there is a need for a system that provides universalscheduling of energy generation and load. There also is a need for asystem that provides universal control over the generation of energy.There is a related need for a system that allows customers to choosetheir energy providers, the type of metering that they use, thefrequency at which they change energy suppliers, the number ofsimultaneous suppliers from which they receive electricity, and the loadfollowing providers that adjust their generation to compensate for thecustomers being above or below their preschedules or anticipated energyusage. There is yet another need for a system that permits customers toeasily switch suppliers by telephone or computer. There is also a needfor a system that can track customers' deviation between actual usageand scheduled usage.

SUMMARY

[0007] The present invention is directed to a system for scheduling theprovision of energy in an energy distribution network having a pluralityof energy users receiving energy from at least one of a plurality ofenergy sources. The system comprises memory in communication with theinput. The memory is configured to store at least one schedule for eachenergy user. Each schedule sets forth the predicted energy usage over apredetermined period of time. A processor is in communication with thememory. The processor is configured to sum the schedules of apredetermined set of energy users thereby creating a net schedule.

[0008] Another embodiment of the present invention is directed to asystem for allocating the deviation between an energy user's predictedenergy usage and the energy user's actual energy usage. The systemcomprises means for receiving meter readings of actual energyconsumption for the energy user. Memory is in communication with themeans for receiving meter readings. The memory is configured to store aschedule of anticipated energy usage for a predetermined period and tostore the energy users' meter readings. A processor is in communicationwith the memory. The processor is configured to calculate the differencebetween the schedule and the meter readings thereby forming a deviationbetween anticipated energy use and actual energy use for each energyuser.

[0009] Yet another embodiment of the present invention is a method forscheduling the generation of energy in an energy distribution networkhaving a plurality of energy users receiving energy from at least one ofa plurality of energy sources. The method comprising the steps of:storing a schedule for each energy user, each schedule setting forth thepredicted energy usage for that energy user over a predetermined periodof time; and summing the schedules of a predetermined set of energyusers thereby creating a net schedule.

[0010] Another method that embodies-the present invention is forallocating the deviation between an energy user's predicted energy usageand the energy user's actual energy usage. This method comprising thesteps of: receiving meter readings of actual energy consumption for theenergy user; storing a schedule of anticipated energy usage for apredetermined period; storing the energy users' meter readings; andcalculating the difference between the schedule and the meter readingsthereby forming a deviation between anticipated energy use and actualenergy use for each energy user.

DESCRIPTION OF THE DRAWINGS

[0011]FIG. 1 illustrates the traditional model for a regional electricutility;

[0012]FIG. 2 illustrates the traditional model of a power grid that hasthe regional electric utilities organized into Control Areas;

[0013]FIG. 3 illustrates one possible model for a power system thatutilizes a computer system embodying the present invention;

[0014]FIG. 4 illustrates organization of components in one possiblemodel of a deregulated utility industry that utilizes the power systemshown in FIG. 3;

[0015]FIG. 5 is a functional block diagram illustrating one possibleembodiment of the computer system shown in FIG. 3; and

[0016]FIG. 6 is a block diagram of one possible embodiment of thehardware for implementing the computer system shown in FIGS. 3 and 5.

DETAILED DESCRIPTION

[0017] Various embodiments of the present invention will be described indetail with reference to the drawings, wherein like reference numeralsrepresent like parts and assemblies throughout the several views.Reference to the various embodiments does not limit the scope of theinvention, which is limited only by the scope of the claims attachedhereto.

[0018] In general terms, the present invention is directed to a systemfor coordinating various components and entities in a deregulated energydistribution system. Various embodiments of the present invention can beutilized with the generation and/or distribution of many different typesof energy, including electricity, natural gas, and petroleum.Furthermore, the present invention can be implemented in many differentmodels for the utility industry and is not limited to the particularmodule that is described herein. Thus, for example, the invention can beused in a system that does not include an independent system operator asdescribed below.

[0019] As stated above, the present invention can have many differentembodiments. In one possible embodiment, a system embodying the presentinvention determines the deviation between each customer's scheduledenergy usage and the customer's actual usage of energy. This deviationprovides a basis for allocating the cost of deviation to the customersthat are actually responsible for the deviation in a prorated amount.Thus, customers pay only for their energy usage and not for the excessusage of other customers. In another possible embodiment, a systemembodying the present invention is directed to creating net usageschedules that are used to control the amount of energy output byvarious generators. Creating and using net usage schedules in thismanner helps to maintain balance in the energy distribution system.

[0020] An advantage of this system is that it enables a customer tochoose its desired source of energy. For example, a customer can chooseto continue receiving energy from its traditional energy provider forthe geographic area in which the customer is located. The customer canalso choose to purchase energy from an alternative energy provider ordirectly from a generator. In yet another example, a customer can chooseto purchase energy from multiple and different sources depending on avariety of factors such as the time of day, the day of the week, orwhether the customer's actual energy usage is exceeding its scheduledusage.

[0021] Referring now to the drawings, FIG. 3 illustrates one possiblemodel of a power system 123 that utilizes the present invention. In thispower system 123, a plurality of generators 124, 125, and 126 generateenergy into a transmission network 128. A distribution network 130receives energy from the transmission network and distributes the energyto the loads 132, 134, 136, and 138. A transformer station 131 ispositioned between the transmission network 128 and the distributionnetwork 130. The loads 132, 134, 136, and 138 can be any type ofcustomer, or combinations of different types of customers, includingresidential, commercial, and industrial customers. There are meters 140,142, 144, and 146 that measure the flow of energy between thedistribution network 130 and the loads 132, 134, 136, and 138. There arealso meters 148, 150, 152 that measure the flow of electricity betweenthe generators 124, 125, and 126 and the transmission network 128. Acomputer system 220 is interfaced with, or electrically connected to,the meters 132, 134, 136, 138, 148, 150, and 152.

[0022]FIG. 4 illustrates one possible structure of the electric utilityindustry in a deregulated environment in which a customer 1-7 can chooseits own source of electricity. Within this system, a customer 1-7 canchoose to keep receiving energy from its regional DISCO 219, which isthe traditional regional utility, or choose to switch to an alternativeenergy provider 242.

[0023] An Independent System Operator (ISO) 244 is a regionalorganization that operates the transmission network 130 independently ofits owners. The ISO 244 can operate transmission networks owned byseveral different companies or a single transmission network.Analogously, the ISO 244 can encompass several Control Areas, a singleControl Area, or combine several Control Area into a larger unitaryControl Area. The ISO 244 is responsible for the reliability of thenetworks within its system and have contracted with a generator 225 thatwill provide load-following services. The load-following generator 225with whom the ISO is associated is the default generator that providesexcess electricity when demand exceeds the load scheduled for thenetwork. Although the ISO is described as performing these functions,other structures of the utility industry are possible in which otherentities, such as the Control Areas themselves, perform these functions.

[0024] Another organization such as an independent energy accountant(IEA) 154 provides a central control that coordinates all of thecomponents for the ISO 244. Accordingly, the IEA 154 operates thecomputer system 220 and provides account switching, short-intervalscheduling, and deviation accounting.

[0025] The IEA 154 communicates with the ISO 244; generators 156 and158; the regional DISCO 219; energy providers 242 that receiveload-following from the default generator 225; energy providers 242 thatcontract with alternative load following generators 223; customers, suchas customer 6, that choose to contract directly with a particulargenerator for either their main supply of energy 156 or 158 or theirload following energy provider 223; and customers, such as customer 7,that have short-interval metering. In an alternative model of the energyindustry and the system configuration, control or coordination isprovided by an entity other than the ISO 154. Examples of other entitiesinclude an independent energy scheduling service or a distributioncompany.

[0026] Referring to FIG. 5, the computer system 220 interfaces withenergy meters 200, after-the-fact interval meters 202, short-intervalmeters 204, and generator meters 206. Energy meters 200 do not haveload-profile recorders and typically are used for residential customers.After-the-fact interval meters 202 have built in load-profile recordersand typically have dial-up communications with an entity that has ameter translation system such as a DISCO. After-the-fact interval meters202 typically are used for commercial and light industrial customers.Short-interval meters 204 record energy on a near real-time basis.Short-interval meters 204 typically are used for large industrialcustomers. Generator meters 206 track the output of generators on a nearreal-time basis.

[0027] Meters operating on a near real-time basis take measurements atrelatively short intervals, such as five minute intervals. However, thelength of the interval can vary depending on a variety of factors suchas the capabilities of the meter, the capacity of the communicationsystem to which the meter is linked, and the number of customers. Theshorter the interval between readings the closer that the system is toachieving true real-time measurement. In some possible configurations,therefore, near real-time is synonymous with real-time if the intervalsare short enough.

[0028] A meter translation system 210 includes a communication interface212, a meter data translation and processing system 214, a highprecision time base 216, and a customer load profile history database218. The communication interface 212 provides an interface forafter-the-fact meters 202.

[0029] The communication interface 212 dials up and polls the individualafter-the-fact meters 202 that are installed at various customers. Eachafter-the-fact meter 202 generates a metered load profile, which is aprofile of actual usage that charts actual use over a period of time.That period of time can have various intervals such as 1 day, 1 week, or1 month. When polled by the meter translation system 210, after-the-factmeters 202 download into the meter data translation and processing unit214 both their metered load profile and the meter reading for the end ofthe profiled interval. The meter profiles as well as the actual meterreadings at the start and stop of the profiled interval are stored inthe customer load profile history database 218.

[0030] The time base 216 receives time from a precision atomic clocksource. This high precision time is used to synchronize the clock ineach of the after-the-fact meters 202.

[0031] The standard energy meters 200 are typically read by a meterreader and input into a hand-held meter reading microcomputer 201. Thishand-held meter reading microcomputer 201 is interfaced with the DISCO'selectronic meter reading system 208. If the customer has not elected toswitch to an alternative energy provider, the meter readings are inputinto the DISCO's billing system 203 and the DISCO 219 will generatebilling for that customer in a manner that is known in the art. If thecustomer has elected to switch energy providers, the data from theDISCO's meter reading system 208 is input into the meter data andtranslation and processing 214 of the meter translation system 210. Inan alternative embodiment, the meter readings are also stored in thecustomer load profile history database 218. In yet another alternativeconfiguration, the DISCO meter reading system 208 communicates meterreadings from switched customers directly to the first input interface205 of the computer system 220, which is described in more detail below,rather than communicating the meter readings to the meter translationsystem 210.

[0032] The computer system 220 includes a deviation accounting processor222; a schedule processor 224; first, second, and third input interfaces205, 226, and 228; first and second output interfaces 215 and 230; areal-time database 232; a relational database 234; a reconciliationprocessor 211; a customer verification processor 209; and aprescheduling processor 213. Within this system, the second inputinterface 226, the schedule processor 224, the real-time database 232,and the second output interface 230 form a real-time processor 231 thatenables the computer system 220 to quickly respond to changes incustomer demand so that the generators can adjust the amount of energythat they generate and minimize any imbalances. The processors describedherein can be computer programs or portions of programs such as routinesor objects.

[0033] The relational database 234 stores information relating todemographics, energy metered customers, after-the-fact interval meteredcustomers, short-interval metered customers; generators, including loadfollowing suppliers; and energy providers. Demographic information thatis stored in the relational database includes data regarding generators,energy providers, and customers that have switched to an energy providerother than their geographic DISCO. Each of the generators, energyproviders, and customers is represented by a flag, code, or characterstring. The relational database 234 creates relationships betweengenerators and energy providers that have energy supply contracts,customers and energy providers that have energy supply contracts, andcustomers and generators that have energy supply contracts. In onepossible embodiment, the relational database also contains informationregarding the interval during which the generator or energy provider isscheduled to supply energy.

[0034] Data stored in the relational database 234 regarding energymetered customers 200 includes preschedules, temperature coefficients,adjusted schedules, actual monthly meter readings, reconciled schedules,and deviations. Data regarding after-the-fact interval metered customers202 includes preschedules, temperature coefficients, adjusted schedules,metered load profiles, and deviations. Data regarding short-intervalmetered customers 204 includes preschedules, metered load profiles, anddeviations. Data regarding the generators 206 includes preschedules,adjusted schedules, metered generation profiles, and deviations. Dataregarding the energy providers 242 includes preschedules, temperaturebasis by zip code, the net of adjusted schedules and short-intervalmetering for the energy provider's customers, a net of reconciled andmetered load profiles, and deviations.

[0035] The temperature basis is the predicted temperature. Thetemperature coefficient is a factor that is added to the preschedule forevery degree that the actual temperature differs from the temperaturebasis. It accounts for increased (or decreased) energy usage caused byclimate control units such as air conditioners that result fromunexpected temperature swings. There is a separate temperaturecoefficient for each customer. Additionally, the temperature coefficientis determined through statistical sampling based upon a customer's, or asampling of similar customers', historic energy usage.

[0036] For example, if the temperature basis is 60° and the actualtemperature is 70°, a customer has a first temperature coefficient thatis added to the preschedule 10 times, once for every degree that theactual temperature exceeds the temperature basis of 60°. If thetemperature basis is 80° and the actual temperature is 85°, the samecustomer will have a different temperature coefficient that is added tothe scheduled energy usage 5 times, once for every degree that theactual temperature exceeds the temperature basis of 80°. Knowledge onhow to compute these coefficients is well known in the art.

[0037] The first input interface 205 receives data from the meter datatranslation and processing system 214 and loads that information intothe relational database 234. This data includes the current metered loadprofiles for after-the-fact metered customers 202 and actual meterreadings for energy metered customers 200. In the event that there is afailure in the communication between the meter translation system 210and the after-the-fact meters 202, a historical metered load profilewill be communicated from the customer load-profile database 218 to thefirst input interface 205.

[0038] The second input communication interface 226 is a near real-timeinterface that polls the short-interval meters 204 that are installed atcustomers' facilities and generator meters 206. The short-interval metervalues, are then downloaded from the second input interface 226 to thenear real-time database 232. The second input interface 226 alsoreceives adjusted schedules from other ISOs and IEAs 217. Thisinformation is used to schedule and maintain a balance between ControlAreas and for billing purposes if there is an imbalance created betweenthe Control Areas. The information also enables customers and energyproviders from other Control Areas to purchase energy from a generator206 in the Control Area of the computer system 220.

[0039] Each generator has a generator prescheduling processor 236 thatgenerates a preschedule of electricity that it plans to generate for apredetermined period. Similarly, each energy provider 242 has a loadprescheduling processor 238 that generates schedules or preschedules foreach of its customers. Each preschedule is created through statisticalsampling based upon a customer's, or a sampling of similar customers',historic energy usage. Additionally, each preschedule corresponds to theenergy that the energy provider 242 expects to provide to the customerfor which the preschedule is created. The preschedules are communicatedto the second input interface 228 by means such as e-mail or otherelectronic communications, and are then stored in the relationaldatabase 234. The preschedule can cover any future period. In onepossible embodiment, however, the preschedules cover a 24-hour periodand are created one day in advance of the period that the schedulecovers.

[0040] The prescheduling processor 213 retrieves all of the preschedulesfor a given energy provider from the relational database 234. Thepreschedules are then summed by Control Area 244, energy provider 242,and DISCO 219 to create net preschedules. The net preschedules arestored in the relational database 234 and communicated to the ISO 244,the DISCOs 219, the energy providers 242, and the load followinggenerators 223 via the first output interface 215.

[0041] The schedule processor 224 generates a net adjusted schedule foreach of the energy providers 242. The net adjusted schedule is theschedule of the amount of electricity that customers of the energyprovider 242 expect to use during a given period of time. The netadjusted schedule includes information for all of the energy provider's242 customers, including short-interval metered customers 204,after-the-fact metered customers, and energy metered customers 200. Ingenerating the net adjusted schedule for an energy provider 242, theschedule processor 224 retrieves the customer data and the preschedulefor all of the energy provider's 242 customers, including theshort-interval metered customers 204, after-the-fact metered customers202, and energy metered customers 200.

[0042] The schedule processor 224 also retrieves actual weather datafrom a weather service 240 and the corresponding temperaturecoefficients from the relational database 234. An example of possibleweather data that is retrieved from the weather service includes theactual temperature by zip code. The scheduling processor 224 thencreates an adjusted schedule by adjusting the preschedules forafter-the-fact interval metered customers 202 and energy meteredcustomers 200 on an hourly basis using the temperature coefficientcorrespondence to the temperature basis and the most recent actualtemperature that the computer system 220 has received.

[0043] The schedule processor 224 also compiles a metered load profilefor each of the short-interval customers 206. The metered load profilesof the short-interval metered customers 206, the adjusted schedules forafter-the-fact metered customers 204, and the adjusted schedules forenergy metered customers 200 are summed to create the net adjustedschedule.

[0044] This process of calculating the net adjusted schedule isperiodically performed for each of the generators, energy providers,Control Areas, DISCOs, and other IEAs. In one possible configuration, anew net adjusted schedule is created every five minutes to provide anear real-time schedule so that generators can periodically adjust theamount of energy they are providing to minimize energy imbalance. Inanother configuration, a new net adjusted schedule is calculated inintervals other than five minutes, depending on a variety of factorsincluding communication between the computer system 200 and theperipheral systems as well as processing demands placed on the computersystem 200. The interval could be less than five minutes or considerablygreater than five minutes.

[0045] The scheduling processor 224 also periodically creates aninter-IEA/Control Area schedule. This schedule is used to updateinformation about the balance between Control Areas and inform anycontracted generators in other Control Areas of the size of the loadthat they need to generate to serve customers in their host ControlArea.

[0046] The scheduling processor 224 stores the weather information,preschedules, adjusted schedules, and short-interval metered loadprofiles in the real-time database 232. Storing this information in thereal-time database 232 enables the schedule processor 224 to quicklyretrieve it for updating or adjusting the schedules. The scheduleprocessor 224 also stores the short-interval metered load profiles andthe adjusted schedules in the relational database 234 to create ahistorical record of data.

[0047] The net adjusted schedule is output from the schedule processor224 via the second output interface 230 to the energy providers 242, theISO 244, the load following providers 223, the DISCO 219, and other IEAsand Control Areas 221 that might have a need for the adjusted schedule.The energy providers 242 can use this information for a variety ofpurposes such as computing an alternate net adjusted generationschedule, keeping historical records, billing purposes, and accountingpurposes. The alternate net adjusted schedule is an alternate generationschedule that determines how much to adjust the energy being purchasedfrom generators and load following generators as the deviations aredetermined. The alternate net adjusted schedule is then communicatedback to the real-time database 232 via the second input interface 226.The scheduling processor 224 then uses this information to adjust theschedules of the appropriate generators and load following generators.

[0048] In an alternative embodiment, the alternate net adjustedgeneration schedule is also communicated directly from the energyproviders 242 to the load following generators 223. The load-followinggenerators can use the alternate net adjusted generation schedule forbilling and to quickly adjust their generation to match customer demandand maintain balance of the system.

[0049] The ISOs 244 use the net adjusted schedule as a measure of theamount of energy that must be available on the network at any giventime. The ISO 244 compares the net adjusted schedules with the netpreschedules to assist in maintaining reliability. This comparison, forexample, is used to determine how much energy the load-followinggenerators must provide in order to meet customer demand and maintain abalanced power system. In another example, this comparison is used toadjust the output of load-following generators with whom customers havecontracted 223 in order to minimize dependence on the ISO's defaultload-following generators 225 to meet demand and balance the powersystem.

[0050] The second output interface 230 also communicates in nearreal-time the net adjusted schedules to load-following generators 223with whom particular energy providers have independently contracted. Inthis situation, the individual contracted load-following generator 223will increase or decrease generation of energy to follow the energyprovider's or customer's adjusted schedule.

[0051] Inter-Control Area schedules are communicated from the secondoutput interface 230 to the other IEAs and Control Areas 221, which usethis information for generating their own load schedules. Thisinformation permits a customer or energy provider in one Control Area tocontract with a generator in another Control Area. This information isalso used to schedule and maintain a balance between adjacent ControlAreas and for billing purposes if the load between adjacent ControlAreas becomes unbalanced.

[0052] The net preschedules and adjusted schedules for all of theswitched customers within each DISCO are transmitted to the DISCOs 219.Each DISCO can then use this information to calculate its ownpreschedule. The DISCO 219 also receives each energy provider's netpreschedule from the first output interface 215.

[0053] The reconciliation processor 211 retrieves the adjusted scheduleor schedules and actual monthly meter readings for every energy meteredcustomer 200 from the relational database 234. The reconciliationprocessor 211 then uses the actual monthly meter reading to scale theadjusted schedule for each customer and create a reconciled schedule.The amount of energy represented in the reconciled schedule issubstantially equivalent to the energy metered customer's actual usage.In one possible embodiment, the total amount of energy represented in acustomer's or energy user's reconciled schedule corresponds to thecustomer's total monthly consumption of energy. The reconciled scheduleis stored in the relational database 234.

[0054] The deviation processor 222 calculates the deviation between theadjusted schedule and the actual energy used for each customer and foreach generator. The deviation processor 222 retrieves information fromthe relational database 234 for each customer. For energy meteredcustomers 200, the deviation processor 222 retrieves the adjustedschedule and the reconciled schedule. The deviation processor 222 thencalculates the difference between the reconciled schedule and theadjusted schedule, which is the deviation. For after-the-fact meteredcustomers and generators, the deviation processor 222 retrieves theadjusted schedule and the metered load and generation profiles from therelational database 234. The deviation processor 222 then calculates thedifference between the metered load profile and the adjusted schedule,which is the deviation. For short-interval metered customers, themetered load profile becomes the adjusted schedule, and there is not adeviation between the adjusted schedule and metered load profile forshort interval metered customers. For customers with multiple energysuppliers the deviations for the customers will be divided based onnegotiated contracts.

[0055] The deviations for individual customers are communicated to eachcustomer's energy provider 242 through the first output communicationinterface 215 and are stored in the relational database 234. Inaddition, the net deviation for each energy provider and generator isprovided to the ISO 244. The energy provider 242 uses the deviation foreach individual customer to allocate the deviation billing from the ISO244 to the individual customers in an amount proportioned to thecustomer's individual deviation.

[0056] The workstation 246 is used to input demographic information foreach customer into the relational database 234. Demographic informationcan include personal information, the identity of the primary energyprovider with whom the customer has contracted, and the identity ofsecondary energy providers with whom the customer has contracted.

[0057] The customer verification processor 209 prevents slamming ofcustomers. Slamming occurs when an energy provider 242 switches acustomer to its service without the customer's permission. The customerverification processor 209 receives requests from the energy provider242 for changes in the customer's chosen energy provider. Thisinformation can be communicated electronically or directly from theenergy provider 242 to the customer verification processor 209.Alternatively, this information can be sent to the IEA, and is thenmanually input to the verification processor 209 at the work station246.

[0058] Upon receiving a request to switch a customer, the verificationprocessor 209 causes a confirmation request to be generated and sent tothe customer 207. The confirmation request can have many possibleformats such as a mailing or a digital certificate. Once theconfirmation from the customer is received, the verification processor209 will update the information in the relational database 234 thatidentifies the customer's 207 new energy provider 242. The confirmationis also communicated to the customer's previous energy provider 242notifying it that the customer switched to another energy provider 242.The same process as described above will be used of a customer selectsan additional energy provider. The change then takes effect after thenext meter reading.

[0059] Referring now to FIG. 6, one possible implementation of thecomputer system 220 has four servers 300, 302, 304, and 306. The firstserver 300 stores the relational database and executes the non real-timeprocesses. These processes include the customer verification processor209, deviation accounting processor 222, reconciliation processor 211,and prescheduling processor 213. The second server 302 stores thereal-time database and executes the scheduling processor 224, which is areal-time processor. The third server 304 includes the second input andthe second output interfaces 226 and 230, which are real-timeinterfaces. The fourth server 306 includes the first and second inputinterfaces 205 and 228, and the first output interface 215. In thisconfiguration, execution of the real-time processes is not slowed byprocessing demands of the non real-time applications or the real-timecommunication. Similarly, the real-time communication is not slowed byprocessing demands of the applications or non real-time communication.All four servers 300, 302, 304, and 306 are microprocessor-based systemsand run the UNIX operating system, or another similar operating system.In one possible embodiment, the servers have memory and utilize a 400MHz Pentium II microprocessor with a 100 MHz bus or similar state-of theart server.

[0060] The third server 304 communicates with a router 308. In turn, therouter 308 is in communication with a plurality of digital service units310, which provide an interface with communication links to peripheralsystems that have a need to communicate with the computer system 220 ona real-time basis. Examples of peripheral systems that might communicatethrough the router include energy providers, short-interval meteredcustomers, ISOs, generators, IEAs, and DISCOs. The digital service units310 provide data translation and drivers. In one possible embodiment,the communication links are direct and dedicated connections such as aT1 span and can form a wide area network. Other embodiments have othertypes of communication links to peripheral systems.

[0061] The fourth server 306 is also communicates with the router 322.In turn, the router 322 is in communication with a plurality of digitalservice units 312 that provide an interface for communication links thatdo not have a need to communicate with the computer system 220 on areal-time basis. Examples of peripheral systems that might communicatethrough the router 322 include the weather service, energy providers,DISCO's, meter translation systems, generators, and customers. In onepossible embodiment, these communication links are dedicated lines suchas a T1 span. Other embodiments might communicate over some othersuitable type of communication network such as the Internet or ISDNlines. Additionally, the router 322 is linked to a modem bank 314, whichprovides data communication over the public telephone network. Suchcommunication can be used for receiving information such as switchinginformation from customers, monthly translation data from the metertranslation system 210, or monthly readings from energy meters receivedfrom the DISCO.

[0062] The first, second, third, and fourth servers 300, 302, 304, and306 are connected to a LAN 316 that operates according to the ETHERNETstandard, or another standard network configuration. Other peripheralequipment connected to the LAN include at least one work station 246, atleast one printer 318, and tape back-up equipment 320 or back-upservice. In one embodiment, the work station 246 is a PC computer thatincludes a 400 MHz Pentium II microprocessor and 100 MHz data bus andoperates the Windows NT operating system.

[0063] The various embodiments described above are provided by way ofillustration only and should not be construed to limit the invention.Those skilled in the art will readily recognize various modificationsand changes that may be made to the present invention without followingthe example embodiments and applications illustrated and describedherein, and without departing from the true spirit and scope of thepresent invention, which is set forth in the following claims.

The claimed invention is:
 1. A system for scheduling the generation ofenergy in an energy distribution network having a plurality of energyusers receiving energy from at least one of a plurality of energysources, the system comprising: memory in communication with the input,the memory configured to store at least one schedule for each energyuser, each schedule setting forth the predicted energy usage over apredetermined period of time; and a processor in communication with thememory, the processor configured to sum the schedules of a predeterminedset of energy users thereby creating a net schedule.
 2. The system ofclaim 1 wherein schedules relate energy usage to a predetermined periodof time.
 3. The system of claim 2 wherein each schedule sets forth theenergy user's predicted consumption of energy from a predeterminedenergy provider.
 4. The system of claim 3 wherein a plurality ofschedules correspond to the predicted energy usage of the energy user,at least one of the schedules setting forth the energy user's predictedconsumption of energy from a first predetermined energy provider and atleast one of the schedules setting forth the energy user's predictedconsumption of energy from a second predetermined energy provider. 5.The system of claim 1 wherein each schedule is a preschedule, eachpreschedule covering a future period of time.
 6. The system of claim 1wherein the processor is configured to recalculate the net schedule foreach energy provider after a predetermined interval.
 7. The system ofclaim 6 wherein the interval between recalculations is less than aboutone hour.
 8. The system of claim 6 further comprising an interface incommunication with the processor, the interface configured to receivetemperature forecasts, wherein: the memory is configured to storetemperature coefficients, each temperature coefficient corresponding toa particular energy user; and the processor is configured to retrievethe temperature coefficient for a particular energy user and adjust theschedules by the temperature coefficients thereby creating adjustedschedules, and to form a net adjusted schedule, the net adjustedschedule being the sum of the adjusted schedules.
 9. The system of claim1 wherein: some of the customers are metered by short-interval meters,the short interval meters being configured to generate load-profiles;and at least some of the schedules are load-profiles.
 10. The system ofclaim 1 wherein some of the customers are metered by after-the-factinterval meters, the after-the-fact interval meters being configured togenerate load-profiles.
 11. The system of claim 1 wherein the energy iselectricity.
 12. The system of claim 11 wherein the system furthercomprising an interface configured and arranged to output the netschedule.
 13. The system of claim 12 wherein the predetermined set ofenergy users corresponds to a predetermined generator.
 14. The system ofclaim 12 wherein the predetermined set of energy users corresponds to apredetermined load-following generator.
 15. The system of claim 12wherein the predetermined set of energy users corresponds to apredetermined DISCO.
 16. The system of claim 12 wherein thepredetermined set of energy users corresponds to a predeterminedindependent energy provider.
 17. The system of claim 12 wherein thepredetermined set of energy users corresponds to a predetermined controlarea.
 18. The system of claim 12 further comprising means for outputtingthe net schedules.
 19. The system of claim 1 wherein the processor is amicroprocessor.
 20. The system of claim 1 wherein the processor is amicrocomputer.
 21. The system of claim 1 wherein the energy distributionsystem includes generators and energy providers and the memory includesa database relating each customer to at least one of the energyproviders.
 22. A system for allocating the deviation between an energyuser's predicted energy usage and the energy user's actual energy usage,the system comprising: means for receiving a meter reading of actualenergy consumption for the energy user; memory in communication with themeans for receiving a meter reading, the memory being configured tostore a schedule of anticipated energy usage for a predetermined periodand to store the energy users' meter reading; and a processor incommunication with the memory, the processor configured to calculate thedifference between the schedule and the meter reading thereby forming adeviation between anticipated energy use and actual energy use for eachenergy user.
 23. The system of claim 22 wherein schedules relate energyusage to a predetermined period of time.
 24. The system of claim 23wherein each schedule sets forth the energy user's predicted consumptionof energy from a predetermined energy provider.
 25. The system of claim24 wherein a plurality of schedules correspond to the predicted energyusage of the energy user, at least one of the schedules setting forththe energy user's predicted consumption of energy from a firstpredetermined energy provider and at least one of the schedules settingforth the energy user's predicted consumption of energy from a secondpredetermined energy provider.
 26. The system of claim 22 wherein themeter readings from at least some of the energy users include an actualusage profile generated by the energy user's meter.
 27. The system ofclaim 22 wherein the energy is electricity.
 28. A method for schedulingthe generation of energy in an energy distribution network having aplurality of energy users receiving energy from at least one of aplurality of energy sources, the method comprising the steps of: storinga schedule for each energy user, each schedule setting forth thepredicted energy usage for that energy user over a predetermined periodof time; and summing the schedules of a predetermined set of energyusers thereby creating a net schedule.
 29. The method of claim 28comprising the additional step of communicating the net schedule to theenergy provider.
 30. The method of claim 28 comprising the additionalstep of recalculating the net schedule for each energy provider after apredetermined interval.
 31. The method of claim 30 wherein the intervalbetween recalculations is less than about one hour.
 32. The method ofclaim 28 wherein the net schedules are net adjusted schedules, methodcomprising the additional steps of: storing temperature coefficients,each temperature coefficient corresponding to a particular energy user;retrieving the temperature coefficient for a particular energy user;multiplying the schedules by the temperature coefficients, therebycreating adjusted schedules; and wherein the step of summing theschedules of a predetermined set of energy users thereby creating a netschedule includes the step of summing the adjusted schedules of apredetermined set of energy users thereby creating the net adjustedschedules.
 33. A method for allocating the deviation between an energyuser's predicted energy usage and the energy user's actual energy usage,the method comprising the steps of: receiving meter readings of actualenergy consumption for the energy user; storing a schedule ofanticipated energy usage for a predetermined period; storing the energyusers' meter readings; and calculating the difference between theschedule and the meter readings thereby forming a deviation betweenanticipated energy use and actual energy use for each energy used.
 34. Amethod of controlling the output of an energy provider, the methodcomprising the steps of: receiving a net schedule; and adjusting theoutput of the energy provider so that the output is substantially equalto the energy usage specified in the schedule.
 35. The method of claim34 wherein the energy provider is an electrical generator and the stepof adjusting the output of the energy provider includes the step ofincreasing the electrical output of the generator.
 36. The method ofclaim 34 wherein the energy provider is an electrical generator and thestep of adjusting the output of the energy provider includes the step ofdecreasing the electrical output of the generator.
 37. The method ofclaim 34 wherein the net schedule is a net adjusted schedule.
 38. Thesystem of claim 22 wherein the memory is further configured to storetemperature coefficients and the processor is further configured toadjust the schedule as a function of the temperature coefficient beforecalculating the difference between the schedule and the meter reading.39. A system for allocating the deviation between an energy user'spredicted energy usage and the energy user's actual energy usage, thesystem comprising: means for receiving a meter reading of actual energyconsumption for the energy user; memory in communication with the meansfor receiving a meter reading, the memory being configured to store aschedule of anticipated energy usage for a predetermined period and tostore the energy users' meter reading; and a processor in communicationwith the memory, the processor configured to create a reconciledschedule representative of actual energy usage, the total energyrepresented in the reconciled schedule being substantially equivalent toactual energy used by the energy user, the processor being furtherconfigured to calculate the difference between the schedule and thereconciled schedule thereby forming a deviation between anticipatedenergy use and actual energy use for each energy user.
 40. The system ofclaim 38 wherein schedules and reconciled schedules relate energy usageto a predetermined period of time.
 41. The system of claim 38 whereineach reconciled schedule is further equivalent to total monthlyconsumption of the energy user.
 42. The system of claim 22 wherein thememory is further configured to store temperature coefficients and theprocessor is further configured to adjust the schedule as a function ofthe temperature coefficient before calculating the difference betweenthe schedule and the reconciled schedule.